Retrieval tool and methods of use

ABSTRACT

A retrieval tool may include a body having a first end portion and a second end portion. A protrusion may extend laterally from the body proximate the second end portion of the body. The protrusion may have an engaging surface, two opposing side surfaces, and an outer surface. A path of fluid communication may extend from the first end portion of the body, through the body and the protrusion, to an engaging surface of the protrusion. A method for moving a downhole tool in a wellbore may include running a retrieval tool into a wellbore and pumping fluid to the retrieval tool. The retrieval tool may be engaged with the downhole tool, which may cause a path of fluid communication to experience a change in fluid pressure.

CROSS-REFERENCE TO RELATED APPLICATIONS

This application claims the benefit of, and priority to, U.S. patent application Ser. No. 61/906,280 filed on Nov. 19, 2013 and titled “Retrieval Tool and Methods of Use,” which application is expressly incorporated herein by this reference in its entirety.

BACKGROUND

A whipstock is a downhole tool designed to aid in the formation of a secondary (e.g., deviated) borehole off a primary wellbore. The whipstock is run into the primary wellbore and oriented with a directional measurement tool. Once oriented, the whipstock is secured in place with a packer or a mechanical anchor. The whipstock includes a sloped surface that causes a mill to deflect from the central longitudinal axis of the primary wellbore toward the wellbore wall so that the mill may initiate drilling of the secondary wellbore. Some whipstocks are retrievable, and may be moved within, or removed from, the primary wellbore using a retrieval tool such as a “fishing hook.” The whipstock may include a slot and the fishing hook may include a mating feature that can be positioned within the slot.

SUMMARY

A retrieval tool is disclosed in accordance with some embodiments of the present disclosure. The retrieval tool may include a body having a first end portion and a second end portion. A protrusion may extend laterally from the body, and may include an engaging surface. At least one bore may define a path of fluid communication extending from the first end portion of the body to the engaging surface of the protrusion.

In another embodiment, a retrieval tool may include a body having at least one bore extending axially therein. A protrusion may extend laterally from the body and may have an engaging surface in fluid communication with the at least one bore of the body.

In some embodiments a retrieval tool may include a body having two end portions. A protrusion may extend laterally from the body proximate one end portion of the body. The protrusion may have an engaging surface, two opposing side surfaces, and an outer surface. A distance between the two opposing side surfaces may be greater proximate the outer surface than proximate the body. A path of fluid communication may extend from a first end portion of the body, through the body and the protrusion, to the engaging surface of the protrusion.

In another embodiment of the present disclosure, a retrieval tool may include a body having a first end portion and a second end portion. A first axial bore may extend fully or partially through the body between the first end portion and the second end portion. A protrusion may extend laterally from the body proximate the second end portion of the body. The protrusion may have an engaging surface, two opposing side surfaces, and an outer surface, and a distance between the two opposing side surfaces may be greater proximate the outer surface than proximate the body. A lateral bore may be located proximate the second end portion of the body and extend through the protrusion from the first axial bore toward the outer surface of the protrusion. A second axial bore may be located in the protrusion and extend at least partially through the protrusion from the lateral bore to the engaging surface of the protrusion.

A method for moving a downhole tool is also disclosed. An example method may include running a retrieval tool into a wellbore. The retrieval tool may include a body having first and second end portions. A protrusion may extend laterally from the body proximate the second end portion, and a path of fluid communication may extending from the first end portion of the body, through the body and the protrusion, to an engaging surface of the protrusion. Fluid may be pumped or otherwise flowed into the body of the retrieval tool. Fluid may flow at least partially through the path of fluid communication. The protrusion may be engaged with a downhole tool in a way that causes a pressure change in the fluid in the body of the retrieval tool.

In accordance with another method, a retrieval tool may be run into a wellbore. The retrieval tool may include a body having a first end portion and a second end portion. A protrusion may extend laterally from the body proximate the second end portion of the body. A path of fluid communication may extend from the first end portion of the body, through the body and the protrusion, to an engaging surface of the protrusion. The protrusion may engage a corresponding slot in a deflection member. An upper surface of the deflection member defining the slot may contact the engaging surface of the protrusion and at least partially obstruct the path of fluid communication therethrough when the protrusion engages the slot.

BRIEF DESCRIPTION OF THE DRAWINGS

So that the recited features may be understood in detail, a more particular description, briefly summarized above, may be had by reference to one or more embodiments, some of which are illustrated in the appended drawings. It is to be noted, however, that the appended drawings are illustrative embodiments, and are, therefore, not to be considered limiting of its scope. Moreover, while the drawings may be considered to be to scale for some embodiments of the present disclosure, the scale of the drawings is intended to be illustrative and not limiting of the present disclosure.

FIG. 1 is a perspective view of an illustrative downhole retrieval tool, according to one or more embodiments of the present disclosure.

FIG. 2 is a cross-sectional view of the retrieval tool of FIG. 1, according to one or more embodiments of the present disclosure.

FIG. 3 is a perspective view of an illustrative deflection member, according to one or more embodiments of the present disclosure.

FIG. 4 is a cross-sectional view of a system for using a retrieval tool to retrieve a deflection member, according to one or more embodiments of the present disclosure.

FIG. 5 is a cross-sectional view of a retrieval tool sliding along a sloped surface of a deflection member, according to one or more embodiments of the present disclosure.

FIG. 6 is a cross-sectional view of the retrieval tool of FIG. 5 when engaging the deflection member, according to one or more embodiments of the present disclosure.

DETAILED DESCRIPTION

Embodiments described herein generally relate to systems, devices, and methods for retrieving remote tooling. More particularly, some embodiments of the present disclosure relate to retrieving tooling within a wellbore. More particularly still, some embodiments may relate to confirming an engagement between a retrieval tool and a deflection member such as a whipstock.

FIG. 1 is a perspective view of an illustrative downhole retrieval tool 100, according to one or more embodiments. The retrieval tool 100 may include a body 110 having a first end portion 112 and a second end portion 114. In this embodiment, the first end portion 112 may be an upper end portion, while the second end portion 114 may be a lower end portion.

As shown, the body 110 may be elongated and/or substantially cylindrical. The body 110 may have any suitable cross-sectional shape, however, including a circle, an ellipse, an oval, a square, a rectangle, a trapezoid, any other regular or irregular geometric shape, or any combination of the foregoing. Moreover, the size and/or shape of the cross-sectional shape of the body 110 may be constant or may change over the length of the body 110.

According to some embodiments, the body 110 may have one or more protrusions or hooks (one is shown as protrusion 120) extending therefrom. As shown in FIG. 1, some embodiments contemplate the one or more protrusions 120 being located proximate the second end portion 114. The one or more protrusions 120 may extend laterally or radially from the body 110 in some embodiments of the present disclosure.

The one or more protrusions 120 may operate as a hook or other engagement mechanism for engaging a downhole tool that is to be moved in a wellbore. When the operator believes a protrusion 120 is engaged with a slot in the downhole tool, an upward force can be applied to the retrieval tool 100. An increased weight measurement at the surface may also be used to confirm engagement. The increase in the weight measurement may be detected due to the weight of the downhole and/or the resistance from the downhole tool being anchored or stuck in place in the wellbore. When engagement is confirmed, an increased upward force can be applied to release the downhole tool so that it is free to move within the wellbore.

Once the downhole tool has been released, it may be difficult, in some embodiments, to confirm the protrusion 120 of the retrieval tool 100 remains engaged in the slot of the downhole tool. This may be due to the weight of the downhole tool being a small fraction of the weight measured at the surface (e.g., 2% of the total weight). In addition, friction between a drill string and a casing or wellbore wall may cause the measured weight to fluctuate. As such, an operator may be unaware that the protrusion 120 of the retrieval tool 100 has disengaged the slot of the downhole tool until the retrieval tool 100 reaches the surface. The trip up to the surface is a time consuming and costly procedure, which may be for naught if the downhole tool is not retrieved.

In some embodiments, the retrieval tool 100 and/or the protrusions 120 may be configured to provide increased sensitivity to determine when the downhole tool disengages from the protrusion 120. The increased sensitivity may operate using fluid pressure changes, in some embodiments of the present disclosure.

FIG. 2, for instance, is a cross-sectional view of the retrieval tool 100 shown in FIG. 1, according to one or more embodiments. The body 110 of the retrieval tool 100 may have one or more axial openings, channels, or bores (one is shown as axial bore 140) formed at least partially therethrough. In some embodiments, the axial bore 140 may extend from the first end portion 112 of the body 110 to the second end portion 114 of the body 110. In another embodiment, the axial bore 140 may extend from the first end portion 112 toward the second end portion 114 of the body (e.g., to the protrusion 120). In still another embodiment, the axial bore 140 may extend from a location proximate the first end portion 112 of the body 110 to either the protrusion 120 or the second end portion 140 of the body 110. A length of the axial bore 140 may therefore vary, and in some embodiments may have a length that is between 50% and 100% of the length of the body 110. For instance, the length of the axial bore 140 may include lower and/or upper limits that include any of 50%, 60%, 70%, 80%, 90%, or 100% of a length of the body 110, or values therebetween. In other embodiments, the length of the axial bore 140 may be less than 50% the length of the body 110.

A cross-sectional shape of the axial bore 140 may be a circle, an ellipse, an oval, a square, a rectangle, some other regular or irregular geometric shape, or any combination of the foregoing. A cross-sectional area of a cross-section of the axial bore 140 may vary in different embodiments, and in some embodiments may be between 1 cm² and 20 cm². More particularly, in some embodiments the cross-sectional area of the axial bore 140 may be within a range having lower and/or upper limits including any from 1 cm², 2 cm², 4 cm², 6 cm², 8 cm², 10 cm², 15 cm², or 20 cm². For example, the cross-sectional area of the axial bore 140 may be from 1 cm² to 4 cm², from 2 cm² to 6 cm², from 5 cm² to 10 cm ², from 8 cm² to 15 cm², from 10 cm² to 20 cm², at least 1 cm², or up to 20 cm². In other embodiments, the cross-sectional area of the axial bore 140 may be less than 1 cm² or more than 20 cm². Moreover, while the cross-sectional area of the axial bore 140 may remain about constant along a length of the axial bore 140, other embodiments contemplate that the shape and/or size of the axial bore 140 may vary along its length.

In some embodiments, the axial bore 140 may be substantially parallel to, co-axial with, or otherwise aligned with a central longitudinal axis 142 of the body 110. The axial bore 140 may be angled or offset relative to the central longitudinal axis 142. A bore may be considered “axial” when aligned to have at least a component of the direction of the bore extend in a direction parallel to the central longitudinal axis 142. A bore may be considered to be lateral/radial when at least a component of the direction of the bore extends in a direction perpendicular to the longitudinal axis 142.

According to some embodiments, the axial bore 140 may be blocked or obstructed proximate the second end portion 114 of the body 110. In FIG. 2, for instance, a plug 144 or other seal may fully or partially block the axial bore 140 at or near the second end portion 114 of the body 110. When the axial bore 140 is blocked or otherwise obstructed, the axial bore 140 may not be in fluid communication with the environment immediately proximate the second end portion 114, or the axial bore 140 may have reduced fluid communication with the environment. When present, the plug 144 may be positioned at least partially within the axial bore 140 and secured to the body 110 in any suitable manner, including via a threaded connection, a friction fit, an adhesive, through the use of mechanical fasteners (e.g., screws, pins, clips, etc.), or in other manners. In some embodiments, the plug 144 may be positioned around the axial bore 140 (e.g., coupled to the end of the second end portion 114) to obstruct flow out of the axial bore 140.

In some embodiments, one or more radial or lateral bores (four are shown as lateral bores 150) may be formed through the body 110. In some embodiments, the lateral bores 150 may be proximate the first end portion 112 of the body 110. The lateral bores 150 may be axially and/or circumferentially offset from one another along the longitudinal axis 142 of the body 110. A central longitudinal axis 152 through one or more of the lateral bores 150 may be substantially perpendicular to the central longitudinal axis 142 of the body 110, although in other embodiments the central longitudinal axis 152 and the lateral bores 150 may extend at other angles relative to the central longitudinal axis 142. For instance, in some embodiments, the central longitudinal axis 152 may be oriented at an angle that is between 10° and 90° relative to the central longitudinal axis.

According to some embodiments, the lateral bores 150 may provide a path of fluid communication from the axial bore 140 to an outer surface 116 of the body 110. In some embodiments, fluid may flow into the axial bore 140 of the retrieval tool 100 (e.g., through an opening of the axial bore 140 at the first end portion 112). For instance, fluid may be pumped or otherwise flowed down through a drill string (e.g., drill pipe 412 of FIG. 4) from the surface and into the axial bore 140 of the retrieval tool 100. At least a portion of the fluid entering the axial bore 140 may flow from the axial bore 140 and through one or more of the lateral bores 150 to the outer surface 116 of the body 110. When the retrieval tool 100 is within a wellbore, the fluid flowing through one or more of the lateral bores 150 may flow into an annulus formed between the outer surface of the retrieval tool 100 and a casing or wellbore wall, as discussed in more detail herein.

A cross-sectional shape of the lateral bores 150 may be a circle, an ellipse, an oval, a square, a rectangle, some other regular or irregular geometric shape, or any combination of the foregoing. A cross-sectional area of each lateral bore 150 may range from 0.1 cm² to 15 cm² in some embodiments. More particularly, some embodiments contemplate the cross-sectional area of at least a portion of the lateral bores 150 being within a range having lower and/or upper limits that include any of 0.1 cm ², 0.5 cm², 1 cm², 1.5 cm², 2 cm², 4 cm², 6 cm², 8 cm², 10 cm², 15 cm², or values therebetween. For example, the cross-sectional area of one or more of the lateral bores 150 may be from 0.1 cm² to 1 cm², from 1 cm² to 3 cm², from 3 cm² to 5 cm², from 5 cm² to 10 cm², at least 0.1 cm², or up to 15 cm². In other embodiments, the cross-sectional area of a lateral bore 150 may be less than 0.1 cm² or more than 15 cm². The cross-sectional shape and/or area of each lateral bore 150 may be the same or may be different. At least some of the lateral bores 150 may have a nozzle 154 therein. In some embodiments, a nozzle 154 may be configured to control and/or measure the flow rate, direction, pressure, or other characteristic of the fluid flowing through the lateral bore 150.

The protrusion 120 proximate the second end portion 114 of the body 110 may include opposing upper and lower surfaces 122, 124, opposing side surfaces 126 (see FIG. 1), and an outer surface 128. The upper surface 122 (or “engaging” surface) may be substantially planar (as shown), concave, convex, otherwise contoured, or include some combination of the foregoing. In some embodiments, the upper surface 122 may be substantially planar and sloped away from the second end portion 114 of the body 110. Accordingly, an axial distance between the upper surface 122 of the protrusion 120 and the second end portion 114 of the body 110 may increase as a lateral or radial distance between the upper surface 122 of the protrusion 120 and the central longitudinal axis 142 of the body 110 increases. In some embodiments, at least a portion of the upper surface 122 may be angled and non-perpendicular relative to the longitudinal axis 142. The illustrated angle 130 between the upper surface 122 of the protrusion 120 and the central longitudinal axis 142 through the body 110 may be between 10° and 89.5° in some embodiments. More particularly, the angle 130 may be within a range having lower and/or upper limits including any of 10°, 20°, 30°, 40°, 50°, 60°, 70°, 75°, 80°, 85°, 89.5°, or values therebetween. For example, the angle 130 may be from 20° to 40°, from 40° to 60°, from 50° to 70°, from 60° to 80°, from 20° to 85°, at least 10°, or up to 89.5°. In other embodiments, the angle 130 may be less than 10° or more than 89.5°. For instance, the angle 130 may be 90°.

In some embodiments, the upper surface 122 of the protrusion 120 may planar, while in other embodiments the upper surface 122 may be curved or otherwise contoured. For instance, the upper surface 122 may curve away from the second end portion 114 of the body 110 such that the axial distance between the upper surface 122 of the protrusion 120 and the second end portion 114 of the body 110 may increase as a lateral or radial distance between the upper surface 122 of the protrusion 120 and the central longitudinal axis 142 of the body 110 increases. In some embodiments, the radius of curvature (not shown) of the upper surface 122 may range from 0.25 cm to 20 cm. For instance, the radius of curvature of the upper surface 122 may be within a range having lower and/or upper limits including any of 0.5 cm, 1 cm, 2 cm, 3 cm, 4 cm, 6 cm, 8 cm, 10 cm, 15 cm, 20 cm, or values therebetween. For example, the radius of curvature may be from 0.5 cm to 2 cm, from 1 cm to 3 cm, from 2 cm to 5 cm, from 4 cm to 10 cm, from 0.5 cm to 10 cm, at least 0.5 cm, or up to 20 cm. In other embodiments, the radius of curvature of the upper surface 122 may be less than 0.5 cm or more than 20 cm.

A width of the protrusion 120 (i.e., between the opposing side surfaces 126) may, in some embodiments, be constant. In other embodiments, the width of the protrusion 120 may vary. For instance, the width of the protrusion 120 may increase as the lateral or radial distance from the central longitudinal axis 142 of the body 110 increases. As such, the width of the protrusion 120 may be greater proximate the outer surface 128 of the protrusion 120 than proximate the outer surface 116 of the body 110. In some embodiments, the protrusion 120 may have a “dovetail-shaped” profile. Optionally, the outer surface 128 of the protrusion 120 may be substantially planar and substantially parallel to the central longitudinal axis 142, although the outer surface 128 may also be contoured or shaped in other manners in other embodiments.

One or more lateral or radial bores 160 (one of which is shown in FIG. 2) may be formed at least partially through the body 110 proximate the second end portion 114 and/or the protrusion 120 of the body 110. The radial bores 160 may also be formed at least partially through the protrusion 120 in some embodiments. In some embodiments, the one or more radial bores 160 may extend about perpendicular relative to the body central longitudinal axis 142 of the body. Accordingly, and as shown in FIG. 2, a central longitudinal axis 162 through the radial bore 160 may be substantially perpendicular relative to the central longitudinal axis 142 of the body 110. In other embodiments, however, the central longitudinal axis 162 of the one or more radial bores 160 may angled at a non-perpendicular angle relative to the central longitudinal axis 142.

In some embodiments, the one or more radial bores 160 may provide a path of fluid communication from the axial bore 140 to the exterior of the body 110 through the outer surface 128, upper surface 122, or lower surface 124 of the protrusion 120, or through some combination thereof. Optionally, the radial bore 160 may be permanently, fully, partially, or selectively blocked proximate the outer surface 128 of the protrusion 120. For instance, a plug 164 may block or obstruct the radial bore 160. The plug 164 may be positioned at least partially within the radial bore 160 (or around the radial bore 160) and secured to the protrusion 120 via a threaded connection, a friction fit, an adhesive, a mechanical fastener, another mechanism, or some combination thereof. In some embodiments, the plug 164 may be formed integrally with the protrusion 120. In the same or other embodiments, the radial bore 160 may not extend fully through the protrusion 120.

Another opening, channel, or port (e.g., axial bore 170) may further be formed through the protrusion 120 in some embodiments. As shown, the axial bore 170 may extend at least partially between the upper surface 122 of the protrusion 120 and the lower surface 124 of the protrusion 120. Although other orientations are contemplated, a central longitudinal axis 172 of the axial bore 170 may be substantially parallel to the central longitudinal axis 142 of the body 110 and/or about perpendicular relative to the central longitudinal axis 162 of the one or more radial bores 160. In some embodiments, the axial bore 170 may intersect the one or more radial bores 160. The axial bore 170 may be blocked or otherwise obstructed proximate the lower surface 124 of the protrusion 120. For instance, a plug 174 may block, restrict, or otherwise obstruct the axial bore 170 at the lower surface 124 as shown in FIG. 2. The plug 174 may be located at least partially within the axial bore 170 (or located around the axial bore 170) and secured therein via a threaded connection, a friction fit, an adhesive, a mechanical fasteners, other mechanism, or some combination thereof. The plug 174 may also be integrally formed with the protrusion 120, or the axial bore 170 may not extend fully through the protrusion 120 to the lower surface 124.

Cross-sectional shapes of the radial bore 160 and/or the axial bore 170 may be a circle, an ellipse, an oval, a square, a rectangle, other regular or irregular geometric shapes, or some combination of the foregoing. Moreover the cross-sectional shape and/or area of the radial bores 160 and/or the axial bores 170 may vary along their respective lengths. In some embodiments, a cross-sectional area of at least a portion of the radial bore 160 and/or the axial bore 170 may range from 0.1 cm² to 15 cm². For instance, the cross-sectional areas may be within a range having lower and/or upper limits including any of 0.1 cm², 0.5 cm², 1 cm², 1.5 cm², 2 cm², 4 cm² , 6 cm ², 8 cm², 10 cm², 15 cm², or values therebetween. For example, the cross-sectional area of a radial bore 160 and/or axial bore 170 may be from 0.1 cm² to 1 cm², from 1 cm² to 3 cm², from 3 cm² to 5 cm², from 5 cm² to 10 cm², at least 0.1 cm², or less than 15 cm². In still other embodiments, the cross-sectional area of a radial bore 160 and/or axial bore 170 may be less than 0.1 cm² or more than 15 cm².

FIG. 3 is a perspective view of an illustrative deflection member 300 according to one or more embodiments. The deflection member 300 is illustrative of a so-called “whipstock,” but can represent any type of deflection member that may be positioned within a vertical, deviated, or other wellbore or borehole.

In accordance with some embodiments, the deflection member 300 may be anchored against a casing in a wellbore, or the deflection member 300 may be anchored against the interior wall of the wellbore. The deflection member 300 may include a body 310 having a sloped front surface 320. The sloped front surface 320 may be oriented at an angle with respect to a central longitudinal axis 312 of the deflection member 300. The particular slope of the sloped front surface 320 may be fixed or may vary along its length. The slope may also vary between embodiments. According to various embodiments, the slope may be between 1° and 45°. For instance, the slope may be within a range having lower and/or upper limits including any of 1°, 5°, 10°, 15°, 20°, 25°, 30°, 40°, 45°, or values therebetween. For instance, the slope of the sloped front surface 320 may be from 1° to 5°, from 5° to 10°, from 10° to 15°, from 15° to 20°, from 20° to 30°, from 30° to 45°, at least 1°, or up to 45°. In other embodiments, the slope of the sloped front surface 320 may be less than 1° or more than 45°. In some embodiments, the slope of the sloped front surface 320 may be measured as degrees per 100 feet (30.5 m). The sloped front surface 320 may be used to redirect a cutting tool such as a drill bit or mill. As an example, when a mill or drill bit is advanced within a wellbore and contacts the deflection member 300, the sloped front surface 320 may cause the mill or drill bit to deflect from the central longitudinal axis of the wellbore toward the wellbore wall so that the mill or drill bit may initiate milling of a window through a casing and/or drilling of a deviated borehole.

According to some embodiments of the present disclosure, the deflection member 300 may include or define a slot 330. As shown in the illustrated embodiment, the slot 330 may be fully or partially defined in the sloped front surface 320 of the deflection member 300. The slot 330 may be defined by a first, upper, or entry portion 332 and a second, lower, or engaging portion 334. The entry portion 332 of the slot 330 may be sized and shaped to have the protrusion 120 of the retrieval tool 100 be inserted laterally/radially therein. The engaging portion 334 of the slot 330 may be sized and shaped to have the protrusion 120 move or slide axially thereto (e.g., in a direction about parallel to the central longitudinal axis 312 of the deflection member 300). The side surfaces of the deflection member 300 that define the engaging portion 334 of the slot 330 may, however, restrict, and potentially prevent, the protrusion 120 from being laterally or radially removed from the slot 330 through the engaging portion 334 (e.g., in a direction about perpendicular to the central longitudinal axis 312 of the deflection member 300).

FIG. 4 illustrates an example downhole system in which embodiments of the present disclosure may be practiced, and FIGS. 5 and 6 illustrate an example manner of using a retrieval tool 100 to engage and/or move a deflection member 300 while in a wellbore 400. FIG. 4 is a cross-sectional view of a retrieval tool 100 being run into the wellbore 400 toward the deflection member 300, according to one or more embodiments. The illustrated wellbore 400 is shown as being substantially vertical; however, it should be appreciated that the wellbore 400 may be horizontal, inclined, angled, deviated, or may extend at other orientations or in other manners.

The retrieval tool 100 may be run into the wellbore 400 using a drilling rig 410. The drilling rig 410 may run the retrieval tool 100 into the wellbore using a drill string including coiled tubing, drill pipe 412, a BHA, or other components, as shown in FIG. 4. As the retrieval tool 100 is run into the wellbore 400, a pump 414 at the surface may cause drilling fluid to flow through the drill pipe 412 and into the retrieval tool 100. The drilling fluid may be used to power one or more downhole motors 420 (e.g., turbine motors, positive displacement motors, etc.) and/or one or more orienting tools to selectively align the protrusion 120 on the retrieval tool 100 with a slot (e.g., slot 330 of FIG. 3) of the deflection member 300.

With reference to FIGS. 2 and 4, drilling fluid may flow into the axial bore 140 of the retrieval tool 100 through a first end portion 112 of the body 110. A first portion of the drilling fluid may flow from the axial bore 140 in the body 110, through the lateral bores 150, and into the annulus 404 formed between an exterior of the body 110 of the retrieval tool 100 and the internal surface of the casing 402 (or wall of the wellbore 400). A second portion of the drilling fluid may flow from the axial bore 140 in the body 110, through the radial bore 160 in the body 110 and protrusion 120, through the axial bore 170 in the protrusion 120, and out the upper surface 122 of the protrusion 120. Fluid flowing out of the upper surface 122 may flow into the annulus 404.

A pressure of the fluid in the drill pipe 412 and/or retrieval tool 100 may be measured by a pressure sensor 416 coupled to a standpipe 418 at the surface (e.g., on the drilling rig 410). It should be appreciated with the benefit of the present disclosure that the pressure of the fluid measured by the pressure sensor 416 at the standpipe 418 may be substantially the same as the pressure of the fluid in the drill pipe 412 and/or in the retrieval tool 100, or potentially proportional thereto. In another embodiment, the pressure of the fluid in the drill pipe 412 and/or retrieval tool 100 may be measured by a downhole component, such as a measurement-while-drilling tool 422. The fluid may have a first pressure before the protrusion 120 of the retrieval tool 100 engages the slot 330 of the deflection member 300.

FIG. 5 is a cross-sectional view of the second end portion 114 of the retrieval tool 100 as the retrieval tool 100 slides along the sloped front surface 320 of the deflection member 300, according to one or more embodiments. With reference to FIGS. 4 and 5, the retrieval tool 100 may be run into the wellbore 400 until the retrieval tool 100 contacts the deflection member 300. An operator at the drilling rig 410 may determine that contact has occurred when the weight of the downhole assembly (including the retrieval tool 100) decreases at the surface. As shown, the retrieval tool 100 may be oriented such that the outer surface 128 of the protrusion 120 is in contact with the sloped front surface 320 of the deflection member 300. The retrieval tool 100 may continue to move with respect to the deflection member 300 until the protrusion 120 is aligned with the entry portion 332 of the slot 330.

FIG. 6 is a cross-sectional view of the second end portion 114 of the retrieval tool 100 after the protrusion 120 has engaged with the slot 330 of the deflection member 300, according to one or more embodiments. When the protrusion 120 is aligned with the entry portion 332 of the slot 330, the protrusion 120 may be moved laterally/radially, and inserted into the entry portion 332 of the slot 330. Once the protrusion 120 has entered the entry portion 332 of the slot 330, the retrieval tool 100 may be pulled axially (e.g., back or toward the surface) causing the protrusion 120 to move or slide from the entry portion 332 of the slot 330 at least partially into the engaging portion 334 of the slot 330. In some embodiments, a dovetail connection may be made between the protrusion 120 and the engaging portion 334 of the slot 330, which can restrict, and potentially prevent, the protrusion 120 from laterally disengaging the slot 330 while an axial force (e.g., toward the surface) is applied to the retrieval tool 100. The axial force may be provided by, for instance, suspending the retrieval tool 100 within the wellbore 400 of FIG. 4. Optionally, if weight or a push force is applied to the retrieval tool 100, the protrusion 120 may slide axially in a downhole direction, from the engaging portion 334 of the slot 330, into the entry portion 332 of the slot 330.

When the protrusion 120 is within the engaging portion 334 of the slot 330 and an axial and/or upward force is applied, the upper surface 122 of the protrusion 120 may optionally abut, mate with, or otherwise contact or engage an upper surface 336 of the deflection member 300. The upper surface 336 may at least partially define or border the slot 330. The upper surface 122 of the protrusion 120, and/or the upper surface 336 of the deflection member 300, may include a seal, a gasket, or the like. As a result, when the upper surface 122 of the protrusion 120 contacts the upper surface 336 of the deflection member 300, fluid flow may be at least partially blocked or obstructed through the axial bore 170 of the protrusion 120 proximate the upper surface 122 of the protrusion 120. Such obstruction may restrict, or even prevent, fluid from flowing therethrough into the annulus 404, which in turn may cause the fluid in the drill pipe 412 (see FIG. 4) and/or retrieval tool 100 to increase to a second pressure. In some embodiments, the pressure may increase by between 10 kPa and 10,000 kPa. For instance, the magnitude of the pressure increase may be within a range having lower and/or upper limits including any of 10 kPa, 100 kPa, 500 kPa, 750 kPa, 1,000 kPa, 1,250 kPa, 1,500 kPa, 1,750 kPa, 2,000 kPa, 2,500 kPa, 5,000 kPa, 10,000 kPa, or values therebetween. For example, the magnitude of the pressure may increase be between 500 kPa and 1,000 kPa, between 1,000 kPa and 1,500 kPa, between 1,500 kPa and 2,000 kPa, between 2,000 kPa and 5,000 kPa, between 100 kPa and 5,000 kPa, at least 10 kPa, or up to 10,000 kPa. In some embodiments, the magnitude of the pressure increase may be less than 10 kPa, or more than 10,000 kPa. With reference to FIG. 4, the increase in pressure may be measured by the pressure sensor 416 at the surface and/or by downhole equipment (e.g., the measurement while drilling tool 422). In another embodiment, the measurement-while-drilling tool 422, a pressure sensor within the body 110 of the retrieval tool 100, or another component may be capable of measuring the pressure in the body 110.

With continued reference to FIGS. 4 and 6, a measured increase in pressure may indicate that the protrusion 120 of the retrieval tool 100 is fully and/or properly engaged with the slot 330 of the deflection member 300. Once engagement is confirmed, an increased axial force may be applied to release the deflection member 300 from its anchored position, and the retrieval tool 100 and deflection member 300 may be moved axially within the wellbore 400. If the measured pressure of the fluid subsequently decreases (e.g., to about the first pressure), this may indicate that the protrusion 120 of the retrieval tool 100 has disengaged from the slot 330 of the deflection member 300. When an operator detects a decrease in pressure, the user may avoid continuing to apply the axial force. For instance, an operator may stop pulling the retrieval tool 100 back toward the surface as the deflection member 300 may be left in the wellbore 400 in such a scenario. Rather, the operator may advance the retrieval tool 100 in the wellbore 400 and attempt to re-engage the protrusion 120 of the retrieval tool 100 with the slot 330 of the deflection member 300. In some embodiments, the pressure of the fluid in the drill pipe 412 and/or the retrieval tool 100 may continue to be measured as the retrieval tool 100 and deflection member 300 move within the wellbore 400. In such an embodiment, the measured pressure may indicate an elevated pressure from the time the protrusion 120 of the retrieval tool 100 engages the slot 330 of the deflection member 300, until such time as the deflection member 300 is moved to a desired location (e.g., removed from the wellbore 400).

While embodiments of the present disclosure relate to detecting engagement between a retrieval tool and a deflection member by measuring an increase in drilling fluid pressure, a person having ordinary skill in the art will appreciate, in view of the disclosure herein, that embodiments disclosed herein may be modified to operate in other manners. For instance, a pressure drop may be detected. A seal may be located on an upper surface of a protrusion to restrict fluid flow out of the protrusion. Upon engaging the upper surface of the protrusion with upper surface of a slot in the deflection member, the seal may be broken or weakened. The deflection member may allow fluid flow out of the protrusion and into the annulus such that a pressure drop may occur. If the protrusion is disengaged from the slot, the seal may again form to increase pressure. Accordingly, a disengagement of the retrieval tool and deflection member may be detected.

In the description herein, various relational terms are provided to facilitate an understanding of various aspects of some embodiments of the present disclosure. Relational terms such as “bottom,” “below,” “top,” “above,” “back,” “front,” “left,” “right,” “rear,” “forward,” “up,” “down,” “horizontal,” “vertical,” “clockwise,” “counterclockwise,” “upper,” “lower,” “uphole,” “downhole,” and the like, may be used to describe various components, including their operation and/or illustrated position relative to one or more other components. Relational terms do not indicate a particular orientation for each embodiment within the scope of the description or claims. For example, a component of a downhole tool that is described as a lower element may be further from the surface relative to an upper element while within a vertical wellbore, but may have a different orientation during assembly, when removed from the wellbore, or in a lateral or other deviated borehole. Accordingly, relational descriptions are intended solely for convenience in facilitating reference to various components, but such relational aspects may be reversed, flipped, rotated, moved in space, placed in a diagonal orientation or position, placed horizontally or vertically, or similarly modified. Certain descriptions or designations of components as “first,” “second,” “third,” and the like may also be used to differentiate between identical components or between components which are similar in use, structure, orientation, or operation. Such language is not intended to limit a component to a singular designation. As such, a component referenced in the specification as the “first” component may be the same or different than a component that is referenced in the claims as a “first” component.

Furthermore, while the description or claims may refer to “an additional” or “other” element, feature, aspect, component, or the like, it does not preclude there being a single element, or more than one, of the additional or other element. Where the claims or description refer to “a” or “an” element, such reference is not be construed that there is just one of that element, but is instead to be inclusive of other components and understood as “at least one” of the element. It is to be understood that where the specification states that a component, feature, structure, function, or characteristic “may,” “might,” “can,” or “could” be included, that particular component, feature, structure, or characteristic is provided in some embodiments, but is optional for other embodiments of the present disclosure. The terms “couple,” “coupled,” “connect,” “connection,” “connected,” “in connection with,” and “connecting” refer to “in direct connection with,” or “in connection with via one or more intermediate elements or members.” Components that are “integral” or “integrally” formed include components made from the same piece of material, or sets of materials, such as by being commonly molded or cast from the same material, or machined from the same one or more pieces of material stock. Components that are “integral” should also be understood to be “coupled” together.

Although various example embodiments have been described in detail herein, those skilled in the art will readily appreciate in view of the present disclosure that many modifications are possible in the example embodiments without materially departing from the present disclosure. Accordingly, any such modifications are intended to be included in the scope of this disclosure. Likewise, while the disclosure herein contains many specifics, these specifics should not be construed as limiting the scope of the disclosure or of any of the appended claims, but merely as providing information pertinent to one or more specific embodiments that may fall within the scope of the disclosure and the appended claims. Any described feature may be used in combination with any other feature described herein, even when described with respect to different embodiments. Features and aspects of methods described herein may be performed in any order.

A person having ordinary skill in the art should realize in view of the present disclosure that equivalent constructions do not depart from the spirit and scope of the present disclosure, and that various changes, substitutions, and alterations may be made to embodiments disclosed herein without departing from the spirit and scope of the present disclosure. Equivalent constructions, including functional “means-plus-function” clauses are intended to cover the structures described herein as performing the recited function, including both structural equivalents that operate in the same manner, and equivalent structures that provide the same function. It is the express intention of the applicant not to invoke means-plus-function or other functional claiming for any claim except for those in which the words ‘means for’ appear together with an associated function. Each addition, deletion, and modification to the embodiments that falls within the meaning and scope of the claims is to be embraced by the claims.

While embodiments disclosed herein may be used in oil, gas, or other hydrocarbon exploration or production environments, such environments are merely illustrative. Systems, tools, assemblies, methods, tool retrieval systems, and other components of the present disclosure, or which would be appreciated in view of the disclosure herein, may be used in other applications and environments. In other embodiments, retrieval tools, systems, methods, and components, or other embodiments discussed herein or which would be appreciated in view of the disclosure herein, may be used outside of a downhole environment, including in connection with other systems, including within automotive, aquatic, aerospace, hydroelectric, manufacturing, other industries, or even in other downhole environments. The terms “well,” “wellbore,” “borehole,” and the like are therefore also not intended to limit embodiments of the present disclosure to a particular industry. A wellbore or borehole may, for instance, be used for oil and gas production and exploration, water production and exploration, mining, utility line placement, or myriad other applications.

Certain embodiments and features may have been described using a set of numerical values that may provide lower and/or upper limits. It should be appreciated that a range may be defined by an upper limit, a lower limit, or between a combination of any two values. Numbers, percentages, ratios, measurements, or other values stated herein are intended to include the stated value as well as other values that are about or approximately the stated value, as would be appreciated by one of ordinary skill in the art encompassed by embodiments of the present disclosure. A stated value should therefore be interpreted broadly enough to encompass values that are at least close enough to the stated value to perform a desired function or achieve a desired result. The stated values include at least experimental error and variations that would be expected by a person having ordinary skill in the art, as well as the variation to be expected in a suitable manufacturing or production process. A value that is about or approximately the stated value and is therefore encompassed by the stated value may further include values that are within 10%, within 5%, within 1%, within 0.1%, or within 0.01% of a stated value.

The Abstract included with this disclosure is provided to allow the reader to quickly ascertain the general nature of some embodiments of the present disclosure. The Abstract is submitted with the understanding that it will not be used to interpret or limit the scope or meaning of the claims. 

What is claimed is:
 1. A retrieval tool, comprising: a body having a first end portion and a second end portion; a protrusion extending laterally from the body, the protrusion including an engaging surface; and at least one bore defining a path of fluid communication extending from the first end portion of the body to the engaging surface of the protrusion.
 2. The retrieval tool of claim 1, the protrusion further including two opposing side surfaces and an outer surface, a distance between the two opposing side surfaces being greater proximate the outer surface than proximate the body.
 3. The retrieval tool of claim 1, the protrusion extending laterally from the second end portion of the body.
 4. The retrieval tool of claim 1, the at least one bore including an axial bore extending at least partially through the body from the first end portion toward the second end portion.
 5. The retrieval tool of claim 1, further comprising: a seal configured to obstruct flow out of the at least one bore.
 6. The retrieval tool of claim 1, the at least bore including at least one lateral bore extending from the path of fluid communication to an outer surface of the body.
 7. The retrieval tool of claim 1, the at least one bore including a radial bore extending at least partially into the protrusion.
 8. The retrieval tool of claim 7, the at least one bore including an axial bore in the protrusion and extending at least partially from the radial bore to the engaging surface of the protrusion.
 9. The retrieval tool of claim 1, the path of fluid communication being configured to be at least partially obstructed when the protrusion engages a corresponding slot in a downhole tool.
 10. A retrieval tool, comprising: a body having at least one bore extending axially therein; and a protrusion extending laterally from the body, the protrusion having an engaging surface in fluid communication with the at least one bore of the body.
 11. The retrieval tool of claim 11, the engaging surface of the protrusion being sloped, and an angle between the engaging surface and the central longitudinal axis being from 20° to 85°.
 12. The retrieval tool of claim 11, the engaging surface of the protrusion being curved, and a radius of curvature of the engaging surface being from 0.5 cm to 10 cm.
 13. The retrieval tool of claim 10, the at least one bore including a first axial bore extending through at least a portion of the body, and a radial bore extending from the axial bore into the protrusion, the protrusion further including a second axial bore from the radial bore to the engaging surface.
 14. The retrieval tool of claim 13, further comprising: a path of fluid communication extending through the first axial bore, the radial bore, and the second axial bore.
 15. The retrieval tool of claim 10, the protrusion including a bore extending to the engaging surface, the bore being configured to be at least partially obstructed when the protrusion engages a corresponding slot in a deflection member.
 16. A method of moving a downhole tool, comprising: running a retrieval tool into a wellbore, the retrieval tool including: a body having a first end portion and a second end portion; and a protrusion extending laterally from the body proximate the second end portion, a path of fluid communication extending from the first end portion of the body, through the body and the protrusion, to an engaging surface of the protrusion; flowing fluid into the body of the retrieval tool and at least partially through the path of fluid communication; and engaging the protrusion with a downhole tool within the wellbore, wherein engaging the protrusion with downhole tool includes causing a pressure change in the fluid being flowed into the body of the retrieval tool.
 17. The method of claim 16, wherein engaging the protrusion with the downhole tool includes engaging the engaging surface of the protrusion with an upper surface of the downhole tool to at least partially obstruct the path of fluid communication.
 18. The method of claim 16, wherein a magnitude of the pressure change in the fluid being flowed into the body of the retrieval tool is between 100 kPa and 5000 kPa.
 19. The method of claim 16, wherein causing the pressure change includes increasing a pressure in the fluid being flowed into the body of the retrieval tool.
 20. The method of claim 18, further comprising: orienting the retrieval tool such that the protrusion is aligned with a slot in the downhole tool. 